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US5265685A - Drill bit with improved insert cutter pattern - Google Patents

Drill bit with improved insert cutter pattern Download PDF

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Publication number
US5265685A
US5265685A US07/815,289 US81528991A US5265685A US 5265685 A US5265685 A US 5265685A US 81528991 A US81528991 A US 81528991A US 5265685 A US5265685 A US 5265685A
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US
United States
Prior art keywords
bit
cutting elements
cutting
ridge
face
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Fee Related
Application number
US07/815,289
Other languages
English (en)
Inventor
Carl W. Keith
Ed R. Martin, Jr.
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Dresser Industries Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Dresser Industries Inc filed Critical Dresser Industries Inc
Priority to US07/815,289 priority Critical patent/US5265685A/en
Assigned to DRESSER INDUSTRIES, INC. A DE CORPORATION reassignment DRESSER INDUSTRIES, INC. A DE CORPORATION ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: KEITH, CARL W., MARTIN, ED R., JR.
Priority to BR9205687A priority patent/BR9205687A/pt
Priority to PCT/US1992/011140 priority patent/WO1993013290A1/fr
Priority to DE69217920T priority patent/DE69217920T2/de
Priority to AT93902701T priority patent/ATE149628T1/de
Priority to EP93902701A priority patent/EP0572655B1/fr
Priority to CN92115017A priority patent/CN1035892C/zh
Priority to NO932968A priority patent/NO932968D0/no
Priority to US08/118,909 priority patent/US5346025A/en
Publication of US5265685A publication Critical patent/US5265685A/en
Application granted granted Critical
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: DRESSER INDUSTRIES, INC. (NOW KNOWN AS DII INDUSTRIES, LLC)
Anticipated expiration legal-status Critical
Expired - Fee Related legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/42—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
    • E21B10/43—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/02—Core bits
    • E21B10/04—Core bits with core destroying means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
    • E21B10/56—Button-type inserts
    • E21B10/567—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
    • E21B10/573—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element

Definitions

  • This invention relates generally to drill bits of the type used in drilling through the material comprising a rock formation such as for an oil well or the like. More particularly, this invention is concerned with a fixed cutter bit of the type which, for example, utilizes polycrystalline diamond cutting elements protruding from the face of the bit to cut through the formation material.
  • drill bits In drilling a borehole in the earth such as for the recovery of oil or for other purposes, many different types of drill bits have been used. The choice of the appropriate type of bit to be used depends upon many factors. One of the most important of these factors to be taken into consideration is the range of hardnesses that will be encountered during transitional drilling that is when drilling through layers of differing formation harnesses.
  • roller cone bits are efficiently and effectively used in drilling through formation materials that are of medium to hard hardness.
  • the mechanism for drilling with a roller cone bit is primarily a crushing and gouging action in that the inserts of the rotating cones are impacted against the formation material compressing the material beyond its compressive strength and thereby drilling through the formation.
  • the mechanism for drilling changes from crushing to abrasion.
  • U.S. Pat. No. 2,729,427 One form of a prior art fixed cutter bit for use in hard material formations is shown in U.S. Pat. No. 2,729,427.
  • This patent teaches the use of natural diamond granules embedded in the matrix of the bit body at its face. Specifically, the granules are arranged in annular ridges which are spaced radially from each other with interposed valleys absent of granules.
  • the drilling action resulting from this structure is a combination of abrasion and fracturing of the hard formation material.
  • the diamond granules scour or abrade away concentric grooves while the rock formation adjacent the grooves is fractured and the matrix material around the diamond granules is worn away.
  • each of the blades is comprised of radially spaced sections of diamonds or diamond like cutting elements embedded in a matrix.
  • the body of the blade is of a softer material than the diamond impregnated matrix sections and includes arcuate grooves between radially increasingly larger area matrix sections.
  • the increasing areas of the matrix sections grind at a uniform rate against the formation material while the softer material in the blade body wears away more quickly with the result that ridges are formed in the bottom of the well bore.
  • the ribs are thought to improve the centering stability of the rotating bit and are purposefully kept thin enough for even hard formation material to break down or off by themselves to be washed away with drilling fluid.
  • the fixed cutter drill bits of the foregoing character are not particularly well suited for use in softer formations because not only do they inherently drill at low penetration rates but their drilling surfaces containing the diamond or diamond like cutting elements may be easily clogged with less brittle formation material. As a result, when drilling from a hard formation material and into a softer formation material the penetration rate may actually drop over that which may be achieved in harder formation materials.
  • Another type of mechanism for drilling may be employed.
  • An example of a bit which is particularly designed for stabilized drilling is shown in U.S. Pat. No. 4,932,484.
  • the bit disclosed in this patent utilizes radial sets of cutting elements mounted within supports to protrude from the face of the bit. At least one of the sets of cutting elements extends outward a greater distance from the face of the bit than other cutting elements so that during drilling a bit stabilizing annular groove is formed in the formation material by the extended elements.
  • the cutting elements overlap each other upon progressing radially outward from the rotational axis of the bit so that all of the formation material across the face of the drill bit is cut.
  • the drilling elements or cutters disclosed in U.S. Pat. No. 4,932,484 employ a shearing action to drill through the formation material. Specifically, a sharp aggressive cutting edge on each of the cutters is pushed into the bottom of the borehole as the bit is rotated.
  • the actual mechanics of round polycrystalline diamond cutters of this type when used in soft and medium-soft range formations may be described as a shearing action wherein formation material is removed in layers.
  • U.S. Pat. No. 4,602,691 Another form of fixed cutter bit which is taught to be usable in medium-soft to medium formations is shown in U.S. Pat. No. 4,602,691.
  • This bit is disclosed as including sharp triangular and blunt circular cutting elements in overlapped protruding profile from the face of the bit. Specifically, the triangular elements protrude 0.005 inch farther from the face of the bit than the circular elements and, thus cut small relief kerfs in the formation. The circular elements follow thereafter and dislodge the formation between the kerfs.
  • the general aim of the present invention is to provide a novel fixed cutter bit for use drilling through different formation materials which bit has longer service life and increased penetration rate over a wider range of different formation material harnesses.
  • the primary aim of the present invention is to provide a new and improved polycrystalline diamond drill bit having a service life for use in hard formations expanded to an acceptable length of time.
  • a more particular object of the present invention is to accomplish the foregoing through the use of a novel pattern or spacing relationship between the cutting element cutting edges of the bit so that when drilling, the formation material is cut and fractured in a special configuration whereby the cutting elements and the cut portions of the formation act together to stabilize the bit against lateral movement and thereby avoid destruction of the cutting edges.
  • the primary cutting elements of the bit are arranged in radially spaced groups comprised of one or more elements and, most importantly, in rotated profile, the cutting edges of the elements from one group to the next are spaced radially from each other leaving a gap in the cutting edge profile.
  • Invention also resides in the novel manner of keeping the uncut formation portions or ridges from interfering with the flow of drilling fluid across the face of the bit by removal of the apex of the ridge without use of the cutting edges of the primary cutting elements and before the apex reaches the face of the bit to cut off such fluid flow.
  • one alternative for removal of the apexes of the ridges is provision of unique and much smaller secondary cutting elements which are disposed entirely within the gaps between the groups of primary cutting elements.
  • portions of the supports for the primary cutting elements may be utilized in removing the apexes of the ridges in a non-cutting action.
  • An alternative novel aspect of the present invention lies in uniquely positioning the cutting edges within a rotated profile paralleling the face of the bit and with such edges having extended radial spans and predetermined axial lengths relative to each other.
  • invention also resides in the construction of the bit with radially adjacent cutting elements not overlapped by a cumulative maximum axial amount more than the axial length of either of the cutting elements and while still protruding axially for a distance sufficient to cut the formation with ridges formed between adjacent pairs of cutting elements to a height which will keep the bit from moving laterally when drilling.
  • FIG. 1 is a perspective view of drill bit embodying the novel features of the present invention.
  • FIG. 2 is an enlarged schematic elevational view of one of the cutter elements of the bit shown in engagement with formation material during drilling.
  • FIGS. 3 and 4 are views taken substantially along lines 3--3 and 4--4, respectively, of FIG. 2.
  • FIG. 5 is a plan view showing the arrangement of the cutting elements on the bit face with portions of the bottom hole pattern shown in dashed lines.
  • FIG. 6 is a fragmentary plan view of a portion of a bit face similar to FIG. 4 but showing an alternative version of one of the features of the present invention.
  • FIGS. 7 and 8 are partial cross-sectional views taken substantially along lines 7--7 and 8--8, respectively of FIG. 6.
  • FIG. 9 is a fragmentary plan view similar to FIG. 6 but showing still another alternative version of one of the features of the present invention.
  • FIGS. 10 and 11 are partial cross-sectional views taken substantially along lines 10--10 and 11--11, respectively, of FIG. 9.
  • FIG. 12 is a schematic view of a portion of a prior art cutter element profile.
  • FIG. 13 is a schematic view of a portion of the cutter element profile for an alternative embodiment of a feature of the present invention.
  • FIG. 14 is a combined schematic view similar to FIG. 13 but showing portions of two different cutting element profiles of alternative arrangements of another feature of the present invention.
  • the present invention is embodied in a fixed cutter bit such as a drag bit 20 (see FIG. 1) adapted for drilling through formations of rock to form a borehole.
  • the bit includes a body 21 with an exteriorly threaded connection 22 at one end thereof for connection to a drill string (not shown).
  • formation cutting elements 24 protrude from a face 25 for drilling through formation material when the bit is turned such as by rotation of the tubing string.
  • the drag bit body 21 is formed in a known manner using powdered metal tungsten carbide particles and binder material to form a hard metal cast matrix.
  • the cutting elements may be any of a number of different hard metal materials such as sintered tungsten carbide, polycrystalline diamond or natural diamonds in a matrix material.
  • each cutting element 24 is mounted within a pocket 26 (see FIG. 2) which in turn is formed in a generally radial wing 27 (see FIG. 1).
  • Several of the wings are formed integrally with the bit body being spaced angularly from each other in the face 25.
  • Located between the wings are generally radially extending flow passages 29 through which drilling fluid flows to clean formation cuttings from the bottom of the borehole and between the cutting elements when drilling.
  • the drilling fluid is delivered to the face of the bit through the drill string and a central passage (not shown) in the bit body 21 to exit nozzles 30 and wash across the face of the bit.
  • each of the cutting elements 24 is shown in greater detail in FIG. 2 as including a cylindrical support 31 with one end 33 secured within its pocket such as by means of brazing or the like.
  • the support itself is comprised of a sintered tungsten carbide material which is harder than the body matrix material. Attached to the other end of the support is an extremely hard layer 34 of synthetic polycrystalline diamond material.
  • these layers provide the major cutting surfaces for the bit. Specifically, the outwardly facing periphery of each of the layers defines a cutting edge 35 (also see FIG. 3) for shearing through the formation material to remove a layer 36 of rock formation material as weight and torque are applied through the tubing string to the bit 20 to rotate the bit under pressure against the bottom of the borehole.
  • the cutting elements 24 are arranged on the face 25 of the bit 20 in a unique new pattern so that the bit may drill more quickly and for a longer period of time through a wider range of different formation material harnesses.
  • the cutting elements are arranged to remove formation material from the bottom of the borehole with a novel combination of drilling actions involving both shearing and fracturing of formation material across the bit face 25 to form stabilizing ridges 37 which are removed from the formation primarily without being cut by the cutting elements and without reaching the face of the bit to block the drilling fluid flow for cuttings removal.
  • the cutting elements 24 are arranged in radially spaced groups 24a, 24b, 24c, 24d and 24e (see FIG. 5). Within each group the cutting elements are angularly spaced from each other and the number of elements in each group increases from two to eight upon progressing radially outward from a central axis 39 of the bit. Moreover, within each group midpoints 40a, 40b, (see FIG. 3) of the circular areas of the diamond layers 34 are at common radial positions relative to the axis of the bit. In the exemplary bit, the diameters of the circular areas for all of the diamond layers are the same and the midpoints thereof are spaced axially from the face 25 of the bit approximately the same distance X.
  • this distance is somewhat greater than the radius of the layer 34.
  • the distance Y between midpoints 40a and 40b of adjacent pairs of the diamond layers 34 is greater than the sum of the radii of the circular areas of adjacent layers.
  • the radial width of each such gap 41 is equal to the shortest radial distance between the cutting edges 35a and 35b of adjacent elements.
  • the width of the gap is not substantially greater than the distance X.
  • ridges 37 and grooves 43 are defined by pairs of the grooves 43.
  • the bottoms of the grooves are generally circular in configuration matching the profile of the cutting edges 35a and 35b and leaving the ridge 37 with concave side walls.
  • An apex portion 44 of the ridge 37 connects between the side walls with the ridge extending axially toward the face of the bit between the adjacent cutting elements.
  • novel means are utilized to fracture the apex portion 44 off the ridge 37 before the apex reaches the bit face and blocks off drilling fluid flow.
  • radially outward sides 45 of the cutting element supports 31 are utilized as the means for breaking off the apex portion of the ridge.
  • FIGS. 2 and 4 The manner in which this is achieved is shown most clearly in FIGS. 2 and 4.
  • the support 31 and diamond layer 34 are aligned longitudinally in a direction which is generally tangential (see FIG. 4) to the circular path of rotation of the bit.
  • the elements are longitudinally cocked with respect to vertical by an acute angle Z (see FIG. 2) within the range of five to thirty degrees (5°-30°) and preferably of about twenty degrees (20°).
  • FIGS. 6-8 A variation of the means for removing the apex 44 of the ridge 37 is shown in FIGS. 6-8.
  • an oblong boss 47 is formed integrally with the face 25 of the bit body 21 of the same hard metal matrix of materials and is spaced rotationally behind cutting elements 24 but at the same radial distance from the axis of the bit as one of the cutting elements.
  • An outer surface area 49 (see FIG. 8) of the boss is configured generally complimentary to the shape of the groove 43 but with a radially outward side portion or shoulder 50 located in conflicting position with the apex portion of the ridge as represented by the double crosshatched areas 51 shown in FIGS. 6-8.
  • the outward side portion 50 wedges against the apex 44 of the ridge breaking it off for removal from the bottom of the borehole well by the flow of drilling fluid across the face of the bit.
  • the shoulder 50 extends completely around the periphery of the boss so that a radially inside portion of the shoulder acts against the inside ridge shown in FIG. 8.
  • FIGS. 9-11 Another variation of the means for removal of the apex 44 of the ridge 37 is shown in FIGS. 9-11.
  • a protuberance 53 of bit body matrix material integrally formed with the body 21 of the bit 20 extends axially outward from the face 25 of the bit into the path of the ridge.
  • the protuberance is generally cylindrical in shape and includes an outer end surface 54 (see FIG. 11) which is slanted at an acute angle with respect to the axis of the bit. More particularly, the outer end surface is slanted so as to face in a radially outward direction for engagement with the apex portion of the ridge. This apex portion is shown by the double cross-hatched area 44 in FIG. 11.
  • two grooves 43a and 43b are formed (see FIGS. 10 and 11) by the cutting elements 24a and 24b with the ridge 31 therebetween. Trailing the cutting elements, the protuberance wedges against the apex portion 44 of the ridge breaking formation material radially outward to be washed away with the flow of drilling fluid across the face of the bit.
  • the ridge 37 should be radially thick enough at some position spaced upwardly from the bottom of the groove 43 to provide a reaction surface having enough resistance against the drilling elements 24 so as to keep the bit from moving laterally during rotational drilling.
  • the top of the ridge must be fractured off easily enough so that the apex 44 is kept from reaching the face 25 of the bit and possibly blocking off the flow of drilling fluid and bit failure.
  • the ridges are formed with cutting elements 24 whose cutting edges 35 are of a greater circumferential span relative to their midpoints than for prior drag bits.
  • FIG. 12 is illustrative of the cutting edge span of a typical prior art drag bit and shows a representative rotated profile of three groups 124a, 124b and 124c of cutting elements.
  • a rotated profile is simply a means of illustrating the relative radial positions of various different radial placements of the cutting elements on the face of a bit by depicting all of the positions as if rotated about the axis of the bit onto a single radial line which herein is to the left of an axis 139 of the bit.
  • the arcuate span of the cutting edges 135 is generally accepted to be no greater than ninety six degrees (96°) as measured by the angle S between the formation side intersections of overlapping adjacent profiles relative to the mid-point 140b of the center element 124b.
  • the improved bit 20 of the present invention contemplates a minimum arcuate span of one hundred-twenty degrees (120°) for the cutting edge 35b.
  • the effect of this improved radial spacing relationship between the profiles of the cutting edges is a increased width W of the base of the ridge 37 created between adjacent cutting elements 35 and a related increase in height.
  • the H height of the ridge 37 is approximately one fifth of the diameter of the cutting element 24. More importantly, it is believed that the apex portion 44 of the ridge is removed from the formation more by the aforementioned easier fracturing mechanism than by the shearing mechanism that occurs along the lower most portion of the cutting edge.
  • a small generally triangular area 55 is defined in the ridge between dashed and solid normal load lines 56 and 57, respectively.
  • the dashed normal line 56 is tangent to the bottom of the groove 43c and the solid normal line intersects the lower overlap of the cutting edge profiles 35b and 35c.
  • the ridge area 55 is unsupported by formation material and is susceptible to being broken from the remaining portion of the ridge by cutting element 24b.
  • a mirror image portion (not shown) of the shaded area 55 on the apex 44 of the ridge 37 may be broken off by the action of the radially outermost cutting element 24c.
  • the apex is susceptible to being fractured in both radial directions leaving a lower unfractured ridge of sufficient height and width for supporting the bit against lateral movement.
  • FIG. 14 Another alternate feature of the present invention is illustrated in FIG. 14 wherein secondary cutting elements 59 are mounted on the face 25 of the bit 20 to insure removal of the apex 44 of the ridge 37.
  • the secondary cutting elements are formed of a hard metal material such as sintered tungsten carbide and, in profile, are mounted entirely within the gaps 41 between each adjacent pair of primary cutting elements 24 on the surface of the wings 27.
  • Two different types of secondary cutting elements 59a and 59b are shown in FIG. 14. The element 59b is of the scribe type while the element 59a is provided with a square cutting edge 60.
  • the secondary cutting elements protrude from the face of the bit a distance no greater than the distance X from the face of the bit to the midpoint 40b of the primary cutting element 24b.
  • the secondary cutting elements provide a mechanism for insuring removal of the fractured apex 44 so that formation cuttings from the ridge are deflected and kept from excessively wearing the wing material between adjacent primary cutting elements.
  • the present invention brings to the art a unique fixed cutter bit 20 which is particularly adapted for transitional drilling by the arrangement of the primary cutting elements 24 so as to leave a gap 41 in the bit profile.
  • the gap causes the formation of the ridge 37 which remains uncut from the bottom of the hole but which is instead fractured off and then washed across the face of the bit to be carried to the surface with the drilling fluid.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Crystallography & Structural Chemistry (AREA)
  • Earth Drilling (AREA)
  • Drilling Tools (AREA)
US07/815,289 1991-12-30 1991-12-30 Drill bit with improved insert cutter pattern Expired - Fee Related US5265685A (en)

Priority Applications (9)

Application Number Priority Date Filing Date Title
US07/815,289 US5265685A (en) 1991-12-30 1991-12-30 Drill bit with improved insert cutter pattern
BR9205687A BR9205687A (pt) 1991-12-30 1992-12-21 Broca de perfuraçáo.
PCT/US1992/011140 WO1993013290A1 (fr) 1991-12-30 1992-12-21 Trepan avec outil de coupe ameliore
DE69217920T DE69217920T2 (de) 1991-12-30 1992-12-21 Bohrmeissel mit verbessertem schneideinsatzmuster
AT93902701T ATE149628T1 (de) 1991-12-30 1992-12-21 Bohrmeissel mit verbessertem schneideinsatzmuster
EP93902701A EP0572655B1 (fr) 1991-12-30 1992-12-21 Trepan avec outil de coupe ameliore
CN92115017A CN1035892C (zh) 1991-12-30 1992-12-30 具有改进的嵌接刀刃型式的钻头
NO932968A NO932968D0 (no) 1991-12-30 1993-08-20 Borkrone med forbedret skjaereinnsatsmoenster
US08/118,909 US5346025A (en) 1991-12-30 1993-09-09 Drill bit with improved insert cutter pattern and method of drilling

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US07/815,289 US5265685A (en) 1991-12-30 1991-12-30 Drill bit with improved insert cutter pattern

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US08/118,909 Continuation US5346025A (en) 1991-12-30 1993-09-09 Drill bit with improved insert cutter pattern and method of drilling

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Publication Number Publication Date
US5265685A true US5265685A (en) 1993-11-30

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US07/815,289 Expired - Fee Related US5265685A (en) 1991-12-30 1991-12-30 Drill bit with improved insert cutter pattern
US08/118,909 Expired - Lifetime US5346025A (en) 1991-12-30 1993-09-09 Drill bit with improved insert cutter pattern and method of drilling

Family Applications After (1)

Application Number Title Priority Date Filing Date
US08/118,909 Expired - Lifetime US5346025A (en) 1991-12-30 1993-09-09 Drill bit with improved insert cutter pattern and method of drilling

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US (2) US5265685A (fr)
EP (1) EP0572655B1 (fr)
CN (1) CN1035892C (fr)
AT (1) ATE149628T1 (fr)
BR (1) BR9205687A (fr)
DE (1) DE69217920T2 (fr)
WO (1) WO1993013290A1 (fr)

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WO1996003567A1 (fr) * 1994-07-28 1996-02-08 Flowdril Corporation Outil et procede de forage a trepans fixes
US5531281A (en) * 1993-07-16 1996-07-02 Camco Drilling Group Ltd. Rotary drilling tools
US5549171A (en) * 1994-08-10 1996-08-27 Smith International, Inc. Drill bit with performance-improving cutting structure
US5551522A (en) * 1994-10-12 1996-09-03 Smith International, Inc. Drill bit having stability enhancing cutting structure
US5582261A (en) * 1994-08-10 1996-12-10 Smith International, Inc. Drill bit having enhanced cutting structure and stabilizing features
US5592996A (en) * 1994-10-03 1997-01-14 Smith International, Inc. Drill bit having improved cutting structure with varying diamond density
US5607025A (en) * 1995-06-05 1997-03-04 Smith International, Inc. Drill bit and cutting structure having enhanced placement and sizing of cutters for improved bit stabilization
US5803196A (en) * 1996-05-31 1998-09-08 Diamond Products International Stabilizing drill bit
US5937958A (en) * 1997-02-19 1999-08-17 Smith International, Inc. Drill bits with predictable walk tendencies
US5967245A (en) * 1996-06-21 1999-10-19 Smith International, Inc. Rolling cone bit having gage and nestled gage cutter elements having enhancements in materials and geometry to optimize borehole corner cutting duty
US6161634A (en) * 1997-09-04 2000-12-19 Minikus; James C. Cutter element with non-rectilinear crest
US6241034B1 (en) 1996-06-21 2001-06-05 Smith International, Inc. Cutter element with expanded crest geometry
US6298930B1 (en) * 1999-08-26 2001-10-09 Baker Hughes Incorporated Drill bits with controlled cutter loading and depth of cut
US6367568B2 (en) 1997-09-04 2002-04-09 Smith International, Inc. Steel tooth cutter element with expanded crest
US6394202B2 (en) 1999-06-30 2002-05-28 Smith International, Inc. Drill bit having diamond impregnated inserts primary cutting structure
US6450270B1 (en) 1999-09-24 2002-09-17 Robert L. Saxton Rotary cone bit for cutting removal
US6460631B2 (en) 1999-08-26 2002-10-08 Baker Hughes Incorporated Drill bits with reduced exposure of cutters
US6568492B2 (en) 2001-03-02 2003-05-27 Varel International, Inc. Drag-type casing mill/drill bit
US6659199B2 (en) 2001-08-13 2003-12-09 Baker Hughes Incorporated Bearing elements for drill bits, drill bits so equipped, and method of drilling
US20060048973A1 (en) * 2004-09-09 2006-03-09 Brackin Van J Rotary drill bits including at least one substantially helically extending feature, methods of operation and design thereof
US20070144789A1 (en) * 2005-10-25 2007-06-28 Simon Johnson Representation of whirl in fixed cutter drill bits
US20070151770A1 (en) * 2005-12-14 2007-07-05 Thomas Ganz Drill bits with bearing elements for reducing exposure of cutters
US20070240905A1 (en) * 2006-04-18 2007-10-18 Varel International, Ltd. Drill bit with multiple cutter geometries
US20070284153A1 (en) * 2005-01-26 2007-12-13 Baker Hughes Incorporated Rotary drag bit including a central region having a plurality of cutting structures
US7726415B1 (en) * 2005-04-07 2010-06-01 Ots International, Inc. Fixed cutter drill bit
US20100155151A1 (en) * 2008-12-19 2010-06-24 Varel International Multi-set pdc drill bit and method
WO2010077169A2 (fr) 2008-12-29 2010-07-08 Общество С Ограниченной Ответственностью Научно-Производственное Предприятие "Буринтех" Trépan de forage à pales
US20100263937A1 (en) * 2009-04-15 2010-10-21 Overstreet James L Methods of forming and repairing cutting element pockets in earth-boring tools with depth-of-cut control features, and tools and structures formed by such methods
US20100276200A1 (en) * 2009-04-30 2010-11-04 Baker Hughes Incorporated Bearing blocks for drill bits, drill bit assemblies including bearing blocks and related methods
US20110073369A1 (en) * 2009-09-28 2011-03-31 Baker Hughes Incorporated Earth-boring tools, methods of making earth-boring tools and methods of drilling with earth-boring tools
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CN1035892C (zh) 1997-09-17
US5346025A (en) 1994-09-13
BR9205687A (pt) 1994-05-17
CN1075530A (zh) 1993-08-25
EP0572655B1 (fr) 1997-03-05
DE69217920T2 (de) 1997-08-07
ATE149628T1 (de) 1997-03-15
EP0572655A1 (fr) 1993-12-08
WO1993013290A1 (fr) 1993-07-08
DE69217920D1 (de) 1997-04-10

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